EP2268763A1 - Lost circulation material formulation and method of use - Google Patents
Lost circulation material formulation and method of useInfo
- Publication number
- EP2268763A1 EP2268763A1 EP09714898A EP09714898A EP2268763A1 EP 2268763 A1 EP2268763 A1 EP 2268763A1 EP 09714898 A EP09714898 A EP 09714898A EP 09714898 A EP09714898 A EP 09714898A EP 2268763 A1 EP2268763 A1 EP 2268763A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- lost circulation
- polymer
- circulation material
- microns
- plugging
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 239000000463 material Substances 0.000 title claims abstract description 51
- 238000000034 method Methods 0.000 title claims abstract description 19
- 239000000203 mixture Substances 0.000 title claims description 49
- 238000009472 formulation Methods 0.000 title description 6
- 229920000642 polymer Polymers 0.000 claims abstract description 34
- 239000002245 particle Substances 0.000 claims abstract description 28
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 19
- 230000002902 bimodal effect Effects 0.000 claims abstract description 11
- 239000012530 fluid Substances 0.000 claims description 36
- 238000005553 drilling Methods 0.000 claims description 28
- 230000015572 biosynthetic process Effects 0.000 claims description 13
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 12
- 239000011148 porous material Substances 0.000 claims description 12
- 229910052799 carbon Inorganic materials 0.000 claims description 11
- 230000008961 swelling Effects 0.000 claims description 9
- 241000758789 Juglans Species 0.000 claims description 8
- 235000009496 Juglans regia Nutrition 0.000 claims description 8
- 229920002401 polyacrylamide Polymers 0.000 claims description 8
- 235000020234 walnut Nutrition 0.000 claims description 8
- 239000005909 Kieselgur Substances 0.000 claims description 7
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 7
- 229920001059 synthetic polymer Polymers 0.000 claims description 4
- 230000002708 enhancing effect Effects 0.000 claims description 2
- NIXOWILDQLNWCW-UHFFFAOYSA-M Acrylate Chemical compound [O-]C(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-M 0.000 claims 2
- 239000000654 additive Substances 0.000 claims 1
- 230000000996 additive effect Effects 0.000 claims 1
- 238000011282 treatment Methods 0.000 abstract description 5
- 238000007789 sealing Methods 0.000 abstract description 2
- 238000012360 testing method Methods 0.000 description 20
- 239000006187 pill Substances 0.000 description 11
- 206010017076 Fracture Diseases 0.000 description 10
- 238000005755 formation reaction Methods 0.000 description 10
- 239000004927 clay Substances 0.000 description 5
- 239000002002 slurry Substances 0.000 description 5
- 239000000440 bentonite Substances 0.000 description 4
- 229910000278 bentonite Inorganic materials 0.000 description 4
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 4
- 239000003623 enhancer Substances 0.000 description 4
- GJCOSYZMQJWQCA-UHFFFAOYSA-N 9H-xanthene Chemical compound C1=CC=C2CC3=CC=CC=C3OC2=C1 GJCOSYZMQJWQCA-UHFFFAOYSA-N 0.000 description 3
- 208000010392 Bone Fractures Diseases 0.000 description 3
- 229920001222 biopolymer Polymers 0.000 description 3
- 239000000919 ceramic Substances 0.000 description 3
- 239000006185 dispersion Substances 0.000 description 3
- 239000000839 emulsion Substances 0.000 description 3
- OGJPXUAPXNRGGI-UHFFFAOYSA-N norfloxacin Chemical compound C1=C2N(CC)C=C(C(O)=O)C(=O)C2=CC(F)=C1N1CCNCC1 OGJPXUAPXNRGGI-UHFFFAOYSA-N 0.000 description 3
- 229920001285 xanthan gum Polymers 0.000 description 3
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- 239000012267 brine Substances 0.000 description 2
- 239000003575 carbonaceous material Substances 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 239000008394 flocculating agent Substances 0.000 description 2
- 239000003921 oil Substances 0.000 description 2
- 238000012216 screening Methods 0.000 description 2
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 2
- 230000003068 static effect Effects 0.000 description 2
- 239000000375 suspending agent Substances 0.000 description 2
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- 208000002565 Open Fractures Diseases 0.000 description 1
- 229910000831 Steel Inorganic materials 0.000 description 1
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 1
- 239000010428 baryte Substances 0.000 description 1
- 229910052601 baryte Inorganic materials 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 229920001577 copolymer Polymers 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000010168 coupling process Methods 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 229910003460 diamond Inorganic materials 0.000 description 1
- 239000010432 diamond Substances 0.000 description 1
- 230000004069 differentiation Effects 0.000 description 1
- 239000003995 emulsifying agent Substances 0.000 description 1
- 230000001804 emulsifying effect Effects 0.000 description 1
- 229940082150 encore Drugs 0.000 description 1
- 239000002657 fibrous material Substances 0.000 description 1
- 150000004676 glycans Chemical class 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 239000010439 graphite Substances 0.000 description 1
- 229910002804 graphite Inorganic materials 0.000 description 1
- 239000011396 hydraulic cement Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000004579 marble Substances 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 239000010445 mica Substances 0.000 description 1
- 229910052618 mica group Inorganic materials 0.000 description 1
- 239000002480 mineral oil Substances 0.000 description 1
- 235000010446 mineral oil Nutrition 0.000 description 1
- 231100000252 nontoxic Toxicity 0.000 description 1
- 230000003000 nontoxic effect Effects 0.000 description 1
- 239000011236 particulate material Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 229920000058 polyacrylate Polymers 0.000 description 1
- 229920000768 polyamine Polymers 0.000 description 1
- 229920001282 polysaccharide Polymers 0.000 description 1
- 239000005017 polysaccharide Substances 0.000 description 1
- 230000001902 propagating effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000010959 steel Substances 0.000 description 1
- 229920000247 superabsorbent polymer Polymers 0.000 description 1
- 239000000725 suspension Substances 0.000 description 1
- 239000002023 wood Substances 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/02—Well-drilling compositions
- C09K8/03—Specific additives for general use in well-drilling compositions
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/04—Hulls, shells or bark containing well drilling or treatment fluids
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/18—Bridging agents, i.e. particles for temporarily filling the pores of a formation; Graded salts
Definitions
- the present invention pertains to methods and compositions for preventing or alleviating the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation.
- a large variety of materials have been used or proposed in attempts to cure lost circulation.
- such materials may be divided into four types or categories: fibrous materials, such as shredded automobile tires or sawdust; flaky materials, such as wood chips and mica flakes; granular materials, such as ground nutshells; and slurries, whose strength increases with time after placement, such as hydraulic cement.
- fibrous materials such as shredded automobile tires or sawdust
- flaky materials such as wood chips and mica flakes
- granular materials such as ground nutshells
- slurries whose strength increases with time after placement, such as hydraulic cement.
- Another type of slurry that thickens downhole is made, typically, by dispersing a polyacrylamide in water and then emulsifying the dispersion in a paraffinic mineral oil, typically using a polyamine as an emulsifier. Bentonite is commonly added to such a slurry where it remains in the external or oil phase of the slurry.
- the bentonite rarely if at all contacts the water so the slurry remains relatively thin while being pumped down the drill pipe.
- the emulsion breaks and the bentonite mixes with the water.
- Crosslinking by the polyacrylamide results in a semi-solid mass that thickens further with the bentonite as it is pumped into cracks and fractures in the formation to block the lost circulation.
- U.S. Patent No. 7,066,285 to Mano Shaarpour provides an improved lost circulation material that comprises a blend of a resilient, angular, carbon-based material and a water-swellable, but not water-soluble, crystalline synthetic polymer.
- Preferred carbon-based materials comprise resilient graphite carbon particles and ungraphitized carbon particles.
- Preferred synthetic polymers comprise polyacrylamide, and most preferably a dehydrated crystallized form of cross-linked polyacrylamide that will readily swell following exposure to water or aqueous based fluids. The patent teaches that such swelling may be delayed by salts in the water, such as the use of brine or addition of calcium chloride.
- the present invention provides a unique combination of material types and particle sizes for the treatment of lost circulation.
- the composition of the invention comprises a resilient graphitic carbon having an optimized or bimodal particle size distribution, and optionally a polymer enhancer, that efficiently seals both small pores (as small as about 190 microns) and large fractures (slots as large as about 500 to about 1000 microns), while showing tolerance to high temperatures (as high as about 150°F to about 250 0 F). Flocculants or swellable polymers are preferred polymers for use in the composition.
- the method of the invention uses the composition of the invention in preventing or alleviating loss of drilling fluid or other fluid circulation in a wellbore penetrating a subterranean formation.
- the composition is preferably provided in a weighted or unweighted "pill" for introduction into the wellbore.
- Such "pills” typically comprise the composition blended with a small amount of drilling fluid or brine.
- the amount of the composition used in the pill will depend on the size of the subterranean fracture, opening, or lost circulation zone to be treated. Multiple pills or treatments may be used if needed.
- drilling is stopped while the pill comprising the composition of the invention is introduced into and circulated in the wellbore.
- the composition of the invention will enter lost circulation zones or porous or fractured portions of the formation where it will prevent or retard the entry of drilling and other wellbore fluids. Pressure can be used to squeeze the pill into the lost circulation zone.
- the composition may be added to the drilling fluid and circulated with the drilling fluid during drilling or servicing of the well.
- LCM may be obtained by combining several materials to obtain a composition that has a "bimodal" particle distribution and tolerance to high temperatures.
- the "bimodal" particle distribution provides sealing of small pores (as small as 190 microns) as well as large fissures (such as 500 to 1000 micron slots).
- the bimodal particle distribution is obtained by an optimized design of particle types. Adding or coupling a polymer flocculant or a swellable polymer with the composition may extend the utility or enhance the effectiveness of the composition at high temperatures as will be discussed further below.
- the optimized design of the particle types is obtained by adding together the following components: a finely ground fibrous cellulosic material, such as BAROFIBRE® SF material available from Halliburton Energy Services, Inc.
- RRC resilient graphitic carbon
- STEELSEAL® material available from Halliburton Energy Services, Inc. in Houston, Texas and Duncan, Oklahoma, preferably about 1150 micron d50, preferably about 5% to about 15% of the composition
- ground rubber or a biodegradable material such as, for example, ground walnut shells, preferably about 10-30 mesh, preferably about 5% to about 25% of the composition
- diatomaceous earth preferably about 25 micron d50, preferably about 55% to about 75% of the composition.
- Ground walnut shells may provide further advantages by being ground into different or bimodal sizes, that is, large or larger and small or smaller sizes, such as, for example, about 410-420 micron d50 (small) and about 1100-1200 micron d50 (large).
- the dimension d50 (or dlO) means that 50% by volume of the particles are smaller than the value indicated.
- Table 1 below demonstrates a bimodal particle size distribution for an example preferred composition of the invention in more detail:
- Table 2 below provides data showing that this formulation of Table 1 is effective as a lost circulation material (LCM) for both large pores and fractures.
- the data is from particle plugging testing on fritted disks and slot testing on steel disks, both at 1000 psi differential in 1.25 ppb BARAZAN® D dispersion-enhanced xanthan biopolymer water fluid. Testing in this simple water fluid is preferred to testing in a more complex field mud as the water fluid will not contribute to stopping the lost circulation in the test.
- NPPT Normalized Particle Plugging Test
- NPPT (PPT Value/SL) * SFR.
- the NPPT value is useful for comparing samples in a single test sequence.
- the NPPT value may not be valid for comparing values between different test series. That is, there is not a specific or ideal NPPT value that is indicative of commercial utility, although generally lower NPPT values indicate better lost circulation materials.
- PPTs The Particle Plugging Tests
- the Slot Tests were conducted in a similar apparatus as the Particle Plugging Tests, but the ceramic disk was replaced by a metal disk with a slot of the designated size cut through it. With the smaller pore ceramic size disk, a slower fluid loss could be obtained such that a spurt loss, PPT value and Static Filtration Rate could be calculated if one did not have the total loss of material within the 30 minute test interval.
- the slot tests measured an almost instantaneous fluid loss before the slot plugged, for a successful test.
- Tables 3-11 demonstrate the laboratory screening associated with arriving at lost circulation materials that show promise for field use. These tables also allow comparison of preferred lost circulation materials formulated according to the present invention with other lost circulation materials or potential lost circulation materials having one or more similar components as the fluids of the present invention. Table 12 provides test data for a preferred formulation of the present invention, as described above.
- GSX refers to ground rubber or a ground rubber product and GSR is a poly vulcanized ground rubber product.
- DE refers to diatomaceous earth. DE* is a pseudonym for a commercially available diatomaceous earth (not bimodal) lost circulation material.
- BDF 391 is resilient graphitic carbon sized 1100-1150 micron d50 and BDF 393 is resilient graphitic carbon sized 700-750 micron d50.
- BARAZAN® D PLUS product is a high molecular weight polysaccharide biopolymer.
- BAROFIBRE® SF product is a non-toxic fibrous cellulosic material.
- STEELSEAL® product is a resilient graphitic carbon.
- BARACARB® product is a sized calcium carbonate or ground marble material.
- HYDRO- GUARD® drilling fluid is a water based drilling fluid.
- ENCORE® drilling fluid is an invert emulsion based drilling fluid.
- CLAY-GRABBER® flocculant is a non-ionic, high molecular weight polyacrylamide polymer.
- EZ-MUD® flocculant is a liquid polymer emulsion containing partially hydrolyzed polyacrylamide/polyacrylate (PHPA) copolymer. All trademarked products are available from Halliburton Energy Services, Inc. in Houston, Texas and Duncan, Oklahoma.
- the composition of the present invention may be mixed and sacked for addition as 1 sack per barrel (50 lbs) in water containing 1.0 ppb B ARAZ AN® xanthan biopolymer suspending agent or equivalent suspending agent.
- Such un-weighted pill is optimum for high fluid loss squeeze applications.
- the treatment pill can be weighted with BAROID or other weighting material, when necessary.
- weighting with SWEEP- WATE® selectively sized barite is preferred due to its larger particle size distribution for enhancing the ability of the composition to plug fractures.
- SWEEP-WATE® material is available from Halliburton Energy Services, Inc. in Houston, Texas and Duncan, Oklahoma.
- the composition of the invention can be applied by adding it directly to the drilling fluid system, preferably in the amount of 1 -sack per barrel.
- Table 13 below shows data for slot tests with a composition of the invention in
- Impermeable formations and vugular and large natural fractures can present special problems for lost circulation control during drilling.
- the present invention is nevertheless effective for alleviating lost circulation under such conditions when a swelling polymer enhancer or flocculant is added to the composition, or to the drilling fluid containing the composition, of the invention.
- Suitable swelling polymer enhancers include, for example, DIAMOND SEAL® polymer which is a water swellable but not water soluble crystalline synthetic polymer capable of absorbing hundreds of times its own weight in water, FUSE- IT® material, and LYS ORB® 218 polymer which is a natural superabsorbent polymer, all available from Halliburton Energy Services, Inc. in Houston, Texas and Duncan, Oklahoma.
- Suitable flocculants are EZ-MUD® flocculant and CLAY GRABBER® flocculant, also available from Halliburton Energy Services, Inc. as noted above. Most preferably, such enhancer is added immediately prior to pumping the pill containing the composition of the invention into the wellbore for entry into the subterranean formation.
- Tables 14 and 15 provide data for slot tests and particle plugging tests respectively using a 1.25 ppb of the composition of the invention mixed with water, which may or may not contain BARAZAN® dispersion-enhanced xanthan bioplymer for viscosity and suspension, and to which various concentrations of swelling polymer have been added.
- the composition of the invention is used as a lost circulation material. That is, a pill or plug comprising the composition of the invention is introduced into the wellbore and allowed to circulate through the wellbore at least to the zone needing lost circulation treatment or to the zone where lost circulation is believed to likely occur. The composition of the invention is then allowed to enter such zone.
- Such zone may be or may comprise or include, without limitation, fractures and porous formations.
- the composition of the invention reduces, eliminates or prevents the entry of drilling fluid and/or other well fluids into said zone.
- the composition of the invention is added directly to the drilling fluid system rather than in a pill, and allowed to circulation with the drilling fluid for entry into lost circulation zones.
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Compositions Of Macromolecular Compounds (AREA)
- Sealing Material Composition (AREA)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
Abstract
Description
Claims
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/074,182 US8043997B2 (en) | 2008-02-29 | 2008-02-29 | Lost circulation material formulation and method of use |
PCT/GB2009/000427 WO2009106796A1 (en) | 2008-02-29 | 2009-02-17 | Lost circulation material formulation and method of use |
Publications (2)
Publication Number | Publication Date |
---|---|
EP2268763A1 true EP2268763A1 (en) | 2011-01-05 |
EP2268763B1 EP2268763B1 (en) | 2013-01-02 |
Family
ID=40599925
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP09714898A Not-in-force EP2268763B1 (en) | 2008-02-29 | 2009-02-17 | Lost circulation material formulation and method of use |
Country Status (5)
Country | Link |
---|---|
US (1) | US8043997B2 (en) |
EP (1) | EP2268763B1 (en) |
AR (1) | AR070488A1 (en) |
CA (1) | CA2713715C (en) |
WO (1) | WO2009106796A1 (en) |
Families Citing this family (59)
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US10011763B2 (en) | 2007-07-25 | 2018-07-03 | Schlumberger Technology Corporation | Methods to deliver fluids on a well site with variable solids concentration from solid slurries |
US8490698B2 (en) * | 2007-07-25 | 2013-07-23 | Schlumberger Technology Corporation | High solids content methods and slurries |
US9040468B2 (en) | 2007-07-25 | 2015-05-26 | Schlumberger Technology Corporation | Hydrolyzable particle compositions, treatment fluids and methods |
US8490699B2 (en) | 2007-07-25 | 2013-07-23 | Schlumberger Technology Corporation | High solids content slurry methods |
US9080440B2 (en) | 2007-07-25 | 2015-07-14 | Schlumberger Technology Corporation | Proppant pillar placement in a fracture with high solid content fluid |
US9890319B2 (en) * | 2009-11-18 | 2018-02-13 | Halliburton Energy Services, Inc. | Compositions and systems for combatting lost circulation and methods of using the same |
US8662172B2 (en) | 2010-04-12 | 2014-03-04 | Schlumberger Technology Corporation | Methods to gravel pack a well using expanding materials |
US8505628B2 (en) | 2010-06-30 | 2013-08-13 | Schlumberger Technology Corporation | High solids content slurries, systems and methods |
US8511381B2 (en) | 2010-06-30 | 2013-08-20 | Schlumberger Technology Corporation | High solids content slurry methods and systems |
US8607870B2 (en) | 2010-11-19 | 2013-12-17 | Schlumberger Technology Corporation | Methods to create high conductivity fractures that connect hydraulic fracture networks in a well |
GB201109446D0 (en) * | 2011-06-06 | 2011-07-20 | M I Drilling Fluids Uk Ltd | Methods for reducing permeability of subterranean reservoirs |
WO2012112926A2 (en) | 2011-02-17 | 2012-08-23 | Tesco Corporation | Method and apparatus for strengthening a wellbore |
RU2549950C1 (en) * | 2011-03-11 | 2015-05-10 | Шлюмбергер Текнолоджи Б.В. | Well treatment |
US8530393B2 (en) | 2011-04-15 | 2013-09-10 | Halliburton Energy Services, Inc. | Methods to characterize fracture plugging efficiency for drilling fluids |
WO2012154473A1 (en) | 2011-05-10 | 2012-11-15 | Dow Global Technologies Llc | Curable composition for use as lost circulation material |
US9133387B2 (en) | 2011-06-06 | 2015-09-15 | Schlumberger Technology Corporation | Methods to improve stability of high solid content fluid |
US9109992B2 (en) | 2011-06-10 | 2015-08-18 | Halliburton Energy Services, Inc. | Method for strengthening a wellbore of a well |
US8887808B2 (en) * | 2011-11-09 | 2014-11-18 | Halliburton Energy Services, Inc. | Engineered methods and materials for wellbore strengthening in subterranean operations |
US9803457B2 (en) | 2012-03-08 | 2017-10-31 | Schlumberger Technology Corporation | System and method for delivering treatment fluid |
US9863228B2 (en) | 2012-03-08 | 2018-01-09 | Schlumberger Technology Corporation | System and method for delivering treatment fluid |
US8765645B2 (en) * | 2012-03-19 | 2014-07-01 | Halliburton Energy Services, Inc. | Lost circulation materials and methods of using the same |
US9290687B1 (en) | 2012-06-12 | 2016-03-22 | Fiber Resources, Inc. | Wood-based loss circulation material and method for manufacturing same |
US9388333B2 (en) | 2012-07-11 | 2016-07-12 | Halliburton Energy Services, Inc. | Methods relating to designing wellbore strengthening fluids |
US20140038857A1 (en) | 2012-07-31 | 2014-02-06 | Matthew L. Miller | Lost Circulation Material With A Multi-Modal Large Particle Size Distribution |
US9809736B2 (en) | 2012-08-31 | 2017-11-07 | Halliburton Energy Services, Inc. | Wellbore servicing compositions and methods of making and using same |
US8746339B2 (en) | 2012-09-27 | 2014-06-10 | Halliburton Energy Services, Inc. | Triggerable lost circulation material and method of use |
BR112015010388A2 (en) | 2012-11-09 | 2017-07-11 | Dow Global Technologies Llc | curable crosslinkable composition |
US9528354B2 (en) | 2012-11-14 | 2016-12-27 | Schlumberger Technology Corporation | Downhole tool positioning system and method |
US9284798B2 (en) | 2013-02-19 | 2016-03-15 | Halliburton Energy Services, Inc. | Methods and compositions for treating subterranean formations with swellable lost circulation materials |
US9175529B2 (en) | 2013-02-19 | 2015-11-03 | Halliburton Energy Services, Inc. | Methods and compositions for treating subterranean formations with interlocking lost circulation materials |
US9416306B2 (en) | 2013-02-28 | 2016-08-16 | Halliburton Energy Services, Inc. | Clean fluid loss control additives |
US8739872B1 (en) | 2013-03-01 | 2014-06-03 | Halliburton Energy Services, Inc. | Lost circulation composition for fracture sealing |
US8999898B2 (en) * | 2013-03-15 | 2015-04-07 | Superior Graphite Co. | Drilling fluid additive for loss circulation and wellbore strengthening |
WO2014150431A1 (en) * | 2013-03-15 | 2014-09-25 | Ipmm, Llc | Bridging material for treating lost circulation |
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AR070488A1 (en) | 2010-04-07 |
CA2713715A1 (en) | 2009-09-03 |
WO2009106796A1 (en) | 2009-09-03 |
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